King Saud University, Saudi Arabia
The two-phase displacement in porous media is significant for water flooding “WF” process due to improving oil recovery. EOR methods are then used, and these strongly depend on the reservoir conditions and properties. Based on EOR applications, gas injection has been the second common method in petroleum industry to increase oil recovery. Numerical model for immiscible two-phase flow in three dimensions in porous media and the solution of this model are studied. Porous media in this paper is assumed homogenous porous media. Brine is an aqueous phase which is mimicked Saudi formation brine. Synthetic oil and medium crude oil are used as oleic phase. The effect of pressure, temperature and crude oils factors on WF process has been investigated using commercial software. In order to increase oil recovery after WF process, several techniques in gas injection have been studied, these can be miscibility levels and injection schemes ‘Continuous Gas Injection ‘CGI’, Water Alternating Gas Injection ‘WAGʼ and Simultaneous Water and Gas Injection, ‘SWAGʼ. Solution of numerical model is approved using two methods which are namely Implicit Pressure and Explicit Saturation method and Implicit Pressure and Implicit Saturation. In WF process, oil recovery increases with decreasing the injection pressure due to delay the breakthrough of displacing fluid. Oil recovery for high API is more than oil recovery for medium API because the viscosity ratio between displaced and displacing fluid for high API case is almost equal one so the displacement is piston-like. For miscibility factor, fully miscible CGI has highest oil recovery rather than immiscible and near miscible CGIs. SWAG scheme has more oil recovery comparing with WAG injection as well as CGI. Gas injection in secondary stage is more achievable rather than gas injection in tertiary stage in order to improve macroscopic and microscopic movements between displacing and displaced fluid.
Biography:
Ali AlNetaifi is an Assistant Professor at King Saud University, Saudi Arabia
1China National Petroleum Corporation (CNPC), China
2China National Oil and Gas Exploration and Development Company Ltd., Iraq
3TÜV Rheinland, UAE
A barrier system is designed, operated and maintained to perform one or more safety functions throughout the facility life cycle. Parameters such as the mean time between failures, the mean time to repair and the test intervals are dynamic, kept within confidence intervals and must be constantly managed by teams showing a base line from the so-called burn-in, useful life up to the wear-out phase. This paper works out how the assumption that a safety critical and maintainable items are considered to be as good as new as long as it is functioning, which implies that there is an management framework in place to identify and correct deficiencies of barriers that are in steady state behavior of a cold standby. However such framework must follow continuous improvement to ensure management avoids creating further problems while solving others. Example: Gas detectors, installed near to the above ground segment of flowlines or the wellheads inside well pads for early detection of hydrocarbon release. Unfortunately, the system may dramatically escalate maintenance costs, reduce revenue and increase actions relative to the contribution to risk and safety integrity level achieved. As opposed to the well isolation barriers which also require high number of action teams formed and completed but proportionally high contribution to the risk and safety integrity level in a well pad. A particular case study is presented.
Biography:
João has completed 20 years experience in Risk consulting projects in the oil and gas, petrochemical and mining industries since 1999. His experience has largely been centered on the risk assessment of refineries, onshore process plants and offshore facilities in South America, Middle East and North Sea.
1China National Petroleum Corporation (CNPC), China
2China National Oil and Gas Exploration and Development Company Ltd., Iraq
3TÜV Rheinland, UAE
Oil and Gas Industry, Petrochemical and Refineries and other similar business activities are inherently capital intensive and exposed to risk. This includes exposure to commodity price risk as well as operational expenditure risk. Identification of inefficiencies to decrease costs is key to optimize the risk profile by effectively managing economic margins and safeguarding life, property and the environment. The benefits of using Bowtie diagrams have been realized by organizations world-wide across a variety of business sectors. This paper introduces the approach intended to demonstrate risks As Low As Reasonably Practical into the optimization of barrier management where process safety-related information is taken by disciplines being pushed for further cost cutting without a compromise on safety and downtime. The results demonstrate the required categorization of threats pathways, barriers and consequences to provide more than a pictorial representation but also an input to management of assetsʼ performance and anomalies (if found). Others working in these areas agree that Bowties should highlight weak organizational controls, enabling proactive, sustainable strategies for reducing risk with more focus on performance monitoring, seeking short-term opportunities to reduce losses, overdue actions and improving operating efficiency.
Biography:
João has completed 20 years experience in Risk consulting projects in the oil and gas, petrochemical and mining industries since 1999. His experience has largely been centered on the risk assessment of refineries, onshore process plants and offshore facilities in South America, Middle East and North Sea.
United Arab Emirates University, UAE
Petrel Software is a powerful tool used to construct and simulate petroleum reservoirs and potential hydrocarbon traps. This integrated study uses more than 200 2D available Seismic lines and electrical well logs obtained from the available nine drilled wells in the study area. The main objectives of this study are to evaluate the hydrocarbon potentiality of the area through analysis of the available dataset and identify key uncertainties and their impact on the development of the area. Horizons and faults interpretation were carried out; Seismic attributes and other seismic processing techniques were used. Establishing a complete set of time and depth maps for specific reservoirs, source and seal intervals for evaluation and geologic correlation of the available wells. Exploration of the most hydrocarbon prospective areas for future drilling was highlighted and petrophysical modeling was constructed. Finally, risk assessment and priority list of prospects have been recommended. The main results of this study summarized that, Potential structural (horsts and half grabens), stratigraphic traps could be identified (Four leads have been highlighted and studied), several faulted four way closures structures and several unconformity surfaces, which may constitute stratigraphic traps. In addition, reservoir pinch-outs and onlaps, which are stratigraphic features, contributed to hydrocarbon potentiality. Vertical and lateral distributions of porosity and permeability are highly variable and least certain fact that effect reservoir quality. Seismic attributes and petrophysical modeling may indicate that reservoir quality may be significantly better than expected in particular localities. Certain Source rocks identification and evaluation. Uncertain variable permeability due to digenetic effects. Uncertain sealing quality due to high porosity of claystone and shale may be considered as another risk leads.
Keywords: Geophysical evaluation, Hydrocarbon potentiality, Petrophysical modeling
Biography:
Malaz Osman Ali Mohammed and Fatma Abdulla Mohammed Ahmad Al Tamimy are undergraduate students, working in Sure Plus Project in the department of Geology from United Arab Emirates University, UAE under the supervision of Dr. Amir Mohamed Amin Gabr.
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